This paper was prepared for presentation at the 1999 SPE Asia Pacific Improved Oil Recovery Conference held in Kuala Lumpur, Malaysia, 25–26 October 1999.

D Field is a major oil field located about 130 km offshore Terengganu, eastern Peninsular Malaysia with a water depth of 76 meters in the South China Sea (Refer to Figure 1). The facilities within the field include oil and gas processing plant, water and gas injection facilities, gas compression system and a Floating Storage and Offloading (FSO) where the crude oil is exported (Refer to Figure 2). The field was brought to production in March 1991 with an average oil production of 45,000 barrels of oil per day (BOPD) and peaked at approximately 75,000 BOPD. Water injection has been implemented for pressure maintenance and as part of the field life journey; water alternating gas (WAG) injection will be introduced to enhance oil recovery within the field. Fulfilling the WAG requirement particularly on gas injection, an additional gas compression module called the Compressed Gas Capacity Enhancement (CGCE) was installed to increase the gas compression capacity. In March 2010, D field has successfully completed two major jobs, the CGCE module installation and field turnaround simultaneously under a campaign called 'D-field CGCE Integrated Turnaround' (DuCIT). CGCE module installation comprises of the installation of a 900 metric tonne module onto the existing platform and the turnaround execution manages to complete planned activities including surface facility maintenance and well related works within the same period. DuCIT involved two major parties, D field Operations and the CGCE Project Management. With a huge challenge in coordinating a total of 400 personnel and controlling concurrent activities in a high risk operation, the team manages to complete the turnaround ahead of schedule with zero Loss Time Injury (LTI). DuCIT has been recognized as the best turnaround adhering to the requirements of PETRONAS standards on plant operation and capability. Analysis presented in this paper describes important key success factors in DuCIT execution; they are 1) proper turnaround planning, 2) developing excellent teamwork and 3) prominent operation coordination. The paper also describes the mitigation plans that were in place.

Angsi Field is an offshore field located in offshore Peninsular Malaysia, developed with an integrated oil and gas processing plant, water injection facilities and gas lift infrastructure. The field was brought to oil production at an initial rate about 30 Mstb/d in end 2001. In early 2002, it started gas production at an initial rate of about 300 MMscf/d of gas which is currently maintained at about 300–400 MMscf/d. Crude oil production peaked in 2005 and was followed by a moderate decline over the next three years. Besides crude oil and gas production, the field also produces condensate while producing gas. It was recognized that a proactive field management strategy was required in order to minimize any further production decline and maintain excellent production operations as the field production forecast showed a declining trend. Four key levers for sustaining Angsi's production were identified, namely:prudent reservoir management and reliable water injection;continuous production improvement and unfailing well integrity;facility optimization and operational improvement; andmaintenance of high equipment uptime and infrastructure integrity. On top of those four levers, prudent and integrated production planning was very important in managing the integration of sub-surface and surface aspects. Various sub-surface and surface technologies were sourced with a target of sustaining production and maximizing oil and gas recovery. The look-back analysis presented here describes the use of an integrated approach in production planning and creativity in resolving problems involving reservoir management & well integrity and production operations through teamwork building. Introduction The Angsi Field is located 165 kilometers east of the Kertih coast line in water depth of 70m. The field is developed under the terms set forth in the Gas Production Sharing Contract ("GPSC") between PETRONAS Carigali Sdn Bhd ("Carigali"), ExxonMobil Exploration and Production Malaysia Incorporation ("EMEPMI") and Petroliam Nasional Berhad ("PETRONAS"), the national oil corporation of Malaysia. The field was discovered by drilling Angsi-1, a wildcat well offshore Terengganu, Peninsular Malaysia in 1974, followed by the first three appraisal wells drilled in 1995 and the second two appraisal wells drilled in 1997. The oil is produced from Sand Group I while the gas is produced from Sand Groups I and K. Water injection was identified as the suitable method for reservoir pressure maintenance from the first day of production with a voidage replacement ratio (VRR) target of one. Wells at the Angsi field typically have dual completions and multiple packers to allow sequential or commingled production from multiple zones. This strategy has been implemented to reduce the number of wells while maintaining a high number of drainage points. Prior to mid-2006, the Asset Base management approach was applied where production planning of the Angsi Field, was taking role in managing the exploration and production of Angsi Field and three other blocks in the region. To sustain competitiveness and resilience against the changing business landscape, the Asset Base approach was subsequently replaced by the Functional Base management method. Since then, some changes were made to suit the new functional base.

A Field is an offshore field located at offshore of Peninsular Malaysia, facilitated with an integrated oil and gas processing plant, water injection facilities and gas lift infrastructure. The field was brought to oil production in end of 2001 and achieved the peak production of about 120 Mbopd in 2005. In early of 2002, it started gas production at an initial rate of about 300 MMscf/d which is currently maintained at about 300–350 MMscf/d. The crude oil production peak was followed by a moderate decline over the next three years. Besides crude oil and gas production, the field also produces condensate as by product while producing gas. It was recognized that a proactive field management strategy was required in order to minimize any further production decline as the field production forecast showed a declining trend. Since A Field is one of major gas contributors, its gas production sustainability is very important to fulfill the gas demand in the region. The current gas sources in A Field are natural gas reservoir as the main source and the associated gas from oil production. It was recognized that subsurface and surface integrity is the key success for sustaining A Field gas production. The integration is important to ensure proper planning and execution for gas development within the A Field area as well as sustaining the crude oil production. There are several alternatives to maintain gas production. The analysis presented here describes the use of an integrated approach involving multi-disciplines to achieve the most suitable decision and maximize value creation focusing on A gas sustainability.

Peninsular Malaysia Operations (PMO) is one of three domestic regions of PETRONAS Carigali Sendirian Berhad (PCSB) located in offshore of Peninsular Malaysia. The operations cover six of main operation areas namely PPD-D, PPD-F, PPD-L, PPD-P, PPD-S and PPD-T. Those operation areas have a wide operation ranges: from green to brown fields, from single to multiple products, from onshore terminal to offshore Floating Storage and Offloading (FSO) and Floating Production Storage and Offloading (FPSO), from heavy crude to light crude and from big to small fields. PPD-D area is gas producer; PPD-F, PPD-L, PPD-P and PPD-S areas are crude and gas producers while PPD-T area is onshore crude and gas terminals. PPD-F area is scatter small fields facilitated with one unit of FPSO and one unit of FSO; PPD-L area is a big oil field facilitated with water alternating gas (WAG) injection facilities, gas lift infrastructure and one unit of FSO; PPD-P area is scatter medium to small brown oil and gas fields facilitated with processing plant, water injection facilities, gas compression, gas lift infrastructures, crude pipeline and gas pipeline and PPD-S areas is a big oil and gas fields, facilitated with integrated gas and oil processing plant, water injection facilities, gas lift infrastructure, crude pipeline and gas pipeline. In some oil fields, water injection is applied for reservoir pressure maintenance while water flooding and Enhanced Oil Recovery (EOR) technologies are implemented to maximize oil recovery. Some fields are still producing naturally while in most brown fields, gas lift is suitable to assist the crude production. Production operations comprises of three functions: production planning, field production operations and production logistics. The main scope is crude and gas production and evacuation from the well up to the terminal or exporting point. As the think tank in production operations, production planning consists of three functions: production analyst, field and integrated production planning and hydrocarbon accounting and allocation. In day to day works, production planning is focusing on crude and gas production achievement. Field production operation as the heart of production operations, handles day to day offshore routine activities, process performance improvement, process plant upgrade and new production facility installation. Considering the importance and urgency of capability building, production operations has taken significant measures in developing and helming competent engineers in order to achieve and maintain excellent production operations as well as to sustain technical talent development. Analysis presented in this paper describes important keys in competency development; they are 1) capability mapping, 2) skill development process and 3) measurement and feedback.